Water depth offers the opportunity to enhance BOP control ...mcedd.com/wp-content/uploads/2014/04/Jan-Van-Wijk-Mel-Whitby-Sh… · DEFINITIONS & CAUTIONARY NOTE Reserves: Our use

Water depth offers the opportunity

to enhance

BOP control systems.

Copyright: Shell Global Solutions BV

BOP control systems.

MCE Deepwater Development 2014

Jan van Wijk, Shell P&T

Mel Whitby, Cameron

DEFINITIONS & CAUTIONARY NOTE Reserves: Our use of the term “reserves” in this presentation means SEC proved oil and gas reserves.

Resources: Our use of the term “resources” in this presentation includes quantities of oil and gas not yet classified as SEC proved oil and gas reserves. Resources are consistent

with the Society of Petroleum Engineers 2P and 2C definitions.

Organic: Our use of the term Organic includes SEC proved oil and gas reserves excluding changes resulting from acquisitions, divestments and year-average pricing impact.

Resources plays: our use of the term ‘resources plays’ refers to tight, shale and coal bed methane oil and gas acreage.

The companies in which Royal Dutch Shell plc directly and indirectly owns investments are separate entities. In this presentation “Shell”, “Shell group” and “Royal Dutch Shell” are

sometimes used for convenience where references are made to Royal Dutch Shell plc and its subsidiaries in general. Likewise, the words “we”, “us” and “our” are also used to refer

to subsidiaries in general or to those who work for them. These expressions are also used where no useful purpose is served by identifying the particular company or companies.

‘‘Subsidiaries’’, “Shell subsidiaries” and “Shell companies” as used in this presentation refer to companies in which Royal Dutch Shell either directly or indirectly has control, by having

either a majority of the voting rights or the right to exercise a controlling influence. The companies in which Shell has significant influence but not control are referred to as

“associated companies” or “associates” and companies in which Shell has joint control are referred to as “jointly controlled entities”. In this presentation, associates and jointly

controlled entities are also referred to as “equity-accounted investments”. The term “Shell interest” is used for convenience to indicate the direct and/or indirect (for example, through

our 23% shareholding in Woodside Petroleum Ltd.) ownership interest held by Shell in a venture, partnership or company, after exclusion of all third-party interest.

This presentation contains forward-looking statements concerning the financial condition, results of operations and businesses of Royal Dutch Shell. All statements other than

statements of historical fact are, or may be deemed to be, forward-looking statements. Forward-looking statements are statements of future expectations that are based on


statements of historical fact are, or may be deemed to be, forward-looking statements. Forward-looking statements are statements of future expectations that are based on

management’s current expectations and assumptions and involve known and unknown risks and uncertainties that could cause actual results, performance or events to differ

materially from those expressed or implied in these statements. Forward-looking statements include, among other things, statements concerning the potential exposure of Royal

Dutch Shell to market risks and statements expressing management’s expectations, beliefs, estimates, forecasts, projections and assumptions. These forward-looking statements

are identified by their use of terms and phrases such as ‘‘anticipate’’, ‘‘believe’’, ‘‘could’’, ‘‘estimate’’, ‘‘expect’’, ‘‘intend’’, ‘‘may’’, ‘‘plan’’, ‘‘objectives’’, ‘‘outlook’’, ‘‘probably’’, ‘‘project’’,

‘‘will’’, ‘‘seek’’, ‘‘target’’, ‘‘risks’’, ‘‘goals’’, ‘‘should’’ and similar terms and phrases. There are a number of factors that could affect the future operations of Royal Dutch Shell and could

cause those results to differ materially from those expressed in the forward-looking statements included in this presentation, including (without limitation): (a) price fluctuations in

crude oil and natural gas; (b) changes in demand for Shell’s products; (c) currency fluctuations; (d) drilling and production results; (e) reserves estimates; (f) loss of market share and

industry competition; (g) environmental and physical risks; (h) risks associated with the identification of suitable potential acquisition properties and targets, and successful

negotiation and completion of such transactions; (i) the risk of doing business in developing countries and countries subject to international sanctions; (j) legislative, fiscal and

regulatory developments including potential litigation and regulatory measures as a result of climate changes; (k) economic and financial market conditions in various countries and

regions; (l) political risks, including the risks of expropriation and renegotiation of the terms of contracts with governmental entities, delays or advancements in the approval of

projects and delays in the reimbursement for shared costs; and (m) changes in trading conditions. All forward-looking statements contained in this presentation are expressly

qualified in their entirety by the cautionary statements contained or referred to in this section. Readers should not place undue reliance on forward-looking statements. Additional

factors that may affect future results are contained in Royal Dutch Shell’s 20-F for the year ended 31 December, 2013 (available at www.shell.com/investor and www.sec.gov ).

These factors also should be considered by the reader. Each forward-looking statement speaks only as of the date of this presentation, 08-10 April, 2014. Neither Royal Dutch Shell

nor any of its subsidiaries undertake any obligation to publicly update or revise any forward-looking statement as a result of new information, future events or other information. In

light of these risks, results could differ materially from those stated, implied or inferred from the forward-looking statements contained in this presentation. There can be no assurance

that dividend payments will match or exceed those set out in this presentation in the future, or that they will be made at all.

We use certain terms in this presentation, such as discovery potential, that the United States Securities and Exchange Commission (SEC) guidelines strictly prohibit us from including

in filings with the SEC. U.S. Investors are urged to consider closely the disclosure in our Form 20-F, File No 1-32575, available on the SEC website www.sec.gov. You can also

obtain this form from the SEC by calling 1-800-SEC-0330.

Content

• The drivers for development of the SPRA.

• How does it work (the fundamentals)

• SPRA control system.

• SPRA performance.


• SPRA performance.

• Evaluation of other solutions.

• Prototype testing and FMCEA.

• Conclusions.

• Q&A

Drivers for the development

1. Increased shear and seal capability against MAWHP with sequenced CSR and BSR (shear with CSR + seal with BSR).

2. Prevent significant growth of surface and subsea accumulators to meet requirement 1.

3. Control BOP weight and size.

4. Reliability


4. Reliability

5. Retrofitting the system should be possible on any existing BOP.

6. Cost of the system should must be reasonable.

7. Upgrade of the BOP in phases must be possible to minimize loss of drilling unit uptime.

SPRA basic system

• The SPRA control system

uses:

• de-booster on the open

port of the BOP operator.

• a set of control valves in

the close circuit of the of

the operator.


Wellbore

Pressure

Transfer

barrier

Close

SPM

Close

Close

SPM

Bypass

valve.

Transfer

barrier

bypass

valve.

SPRA bypass

valve.

the operator.

• A transfer barrier.

• ROV bypass valves.

SPRA control

system modes of

operation. SP

M m

an

ifo

ld b

yp

ass

Tra

nsf

er

ba

rrie

r b

yp

ass

SP

RA

by

pa

ss

Auto Close Mode Open Closed Closed

Normal Close Mode Open Closed Open

Pilot Close Mode Closed Closed Closed

SPRA fundamentalsThe optimum SPRA de-intensifier ratio or de-

boosted opening pressure is dependent on:

• The opening pressure supplied by the control

system (1500-2500 psi),

• The strength of the BOP operators,

• The strength of the connection rod / ram

interface,

• The strength of the connection from the


• At 10000 ft WD, the maximum closing pressure on the operator is 5000 + 4340 = 9340 psi.

• The actuator open chamber pressure at 10000 ft is 4450 / 1.54 = 2886 psi.

• Ram differential closing pressure is 9340 - 2886 = 6453 psi !

• Minimum shear ram opening pressure against SW-HSH in the wellbore = 1665 psi

• The strength of the connection from the

operator to the BOP

• The maximum allowable differential across

the operator piston seal(s).

• The strength of the shear ram(s).

SPRA Control system


SPRA control interlocks

• Shear Ram Close activated. SPRA

manifold Open is automatically activated

first (PCM).

• Shear Ram High Pressure Close activated. SPRA manifold Open is automatically activated first (PCM). Close light comes on

• Shear Ram Open activated. SPRA

manifold Open is automatically

activated.


• Shear Ram Block activated. SPRA

manifold Block is automatically

activated

activated first (PCM). Close light comes on too.

• SPRA manifold Open is activated (PCM). A

pop-up will occur, indicating this is a non-

standard operation and asks “do you want

to continue” Yes/No.

• NOTE: Interlocks are timed to maximize the benefit of the PCM !

• NOTE: last function state lights are not indicated for clarity.

SPRA performance


• The non-ideal gas behavior of the pre charge gases (Nitrogen or Helium) in deepwater reduces

the subsea conventional accumulator system efficiency, which does provide the emergency

hydraulic shear and seal force to the BOP.

• With SPRA manifold open function connected to the operator close function, the loss of the

emergency hydraulic shear and seal force to the BOP is compensated with increasing water

depth. The available shear pressure at 10000 ft increases with 174 % compared to a 1280 gal

conventional DM/AS accumulator system.

• The SPRA Pilot Close Mode (PCM) maximizes the pressure to the function. The available shear

pressure at 10000 ft increases with 204 % compared to a 1280 gal conventional DM/AS

accumulator system.

• Open pressure against seawater hydrostatic head in the wellbore

Efficiency of the SPRA• The SPRA is designed

to maximize the

efficiency of surface

and subsea

accumulators in

volume and pressure

delivery to the

function.


• The SPRA initially closes the shear rams on open hole or against the pipe first,

followed by the application of the shear / close pressure to the function

thereafter. This is called the SPRA-Pilot Close Mode (PCM).

function.

• Shear of 14” casing

requires 54 gal from

the accumulators

instead of 71 gal. using

the Pilot Close Mode

Evaluation of other solutionsAccu surfaceAccu Subsea P-Shear DM/AS DM/AS

charge discharge MAWHP Accu Volume

(psia) (psia) (psia) No: US gal Remarks

5000 7050 2251 8 1280 gal current accumulator system (N2)

5000 7950 3151 15 2400 gal accumulator system (N2)




• The SPRA system, using PCM shows that it might be able to outperform a

system that uses 7500 psi accumulator charge pressure.

• An upgrade to 7500 psi subsea charge pressure also provides sufficient

pressure to shear a 14” casing against MAWHP, but requires the installation

of HP piping and a 7500-5000 psi regulator. Further upgrades must be

considered which may include a surface 7500 psi pump and a 7500 psi hot

line reel.


5000 7500 4175 8 1280 SPRA with 1.54 ratio

Prototype testing and FMCEA

• The SPRA system was tested to an equivalent WD of 15000 ft and both de-booster and control system worked as designed.

• Components have in detail been reviewed for their suitability and reliability.

SPRA

System

SPRA prepared for Hyperbaric

Chamber testing


reliability.

• Control system hardware and software must go through an FMECA process as part of QA & QC before installation.

• BOP control software updates must be extensively tested on a simulator control system before installed on the control system.

System

EVO ram

bonnet

Hyperbaric

chamber test

frame

Position for the

SPRA control

system

components

Conclusions

• Weight of the SPRA system for both CSR + BSR is +/- 45000 lbs and required upgrade of the BOP crane.

• The SPRA aims to deliver the shear and seal force needed to support the sequencing of CSR and BSR.

• Design verification showed that the connection rods from the operators must be upgraded to a higher YS NACE compliant CRA material in order to use the de-booster ratio of 1.54. Solutions have been identified.


been identified.

• Installation on existing BOPs is possible.

• Alternative solution for the subsea accumulators will be charging to 7500 psi. Consideration must then be given for installation of a 7500 psi hot line, 7.5K to 5K regulator and 7500 psi pump. Surface accumulator count may also have to be adjusted to provide the shear and seal pressure under normal operations.

Q&A

Raising the

Performance

together


together

Documents

Water depth offers the opportunity to enhance BOP control ...mcedd.com/wp-content/uploads/2014/04/Jan-Van-Wijk-Mel-Whitby-Sh… · DEFINITIONS & CAUTIONARY NOTE Reserves: Our use